CA1228532A - Method of operating a multi-mode downhole tool - Google Patents
Method of operating a multi-mode downhole toolInfo
- Publication number
- CA1228532A CA1228532A CA000528674A CA528674A CA1228532A CA 1228532 A CA1228532 A CA 1228532A CA 000528674 A CA000528674 A CA 000528674A CA 528674 A CA528674 A CA 528674A CA 1228532 A CA1228532 A CA 1228532A
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Abstract
ABSTRACT
Disclosed is a method of operating a multi-mode downhole tool including a drill pipe tester mode and a circu-lation mode and having a longitudinal bore extending there-through. The method comprises running the tool into a well bore on a pipe string; setting a packer in the well bore below the tool to isolate the well bore above the packer from that therebelow; pressure-testing the integrity of the pipe string against a closed bore closure valve disposed in the bore of the tool while the tool is in the drill pipe tester mode; and pressure-testing the seal between the set packer and the wall of the well bore while the tool is in the drill pipe tester mode by increasing well bore pressure above the set packer without opening the bore closure valve or changing the tool to a different operating mode.
Disclosed is a method of operating a multi-mode downhole tool including a drill pipe tester mode and a circu-lation mode and having a longitudinal bore extending there-through. The method comprises running the tool into a well bore on a pipe string; setting a packer in the well bore below the tool to isolate the well bore above the packer from that therebelow; pressure-testing the integrity of the pipe string against a closed bore closure valve disposed in the bore of the tool while the tool is in the drill pipe tester mode; and pressure-testing the seal between the set packer and the wall of the well bore while the tool is in the drill pipe tester mode by increasing well bore pressure above the set packer without opening the bore closure valve or changing the tool to a different operating mode.
Description
so BACKGROUND Of` THE INVENTION
Well testing and stimulation operations are commonly conducted on oil and gas wells in order to determine production potential and -to enhance same if possible. In flow testing a well, a tester valve is lowered into the well on a string of drill pipe above a packer. After the packer is set, the tester valve is opened and closed periodically to determine formation flow, pressure, and rapidity of pressure recovery Also generally included in a testing string are a drill pipe tester valve and a circulation valve above the tester valve, -the former to permit testing the pressure integrity of the string prior to conducting the test, and the latter to permit the circulation of formation fluids out of the string after the test is completed.
It is desirable, particularly when conducting tests on offshore wells, to employ a testing string which requires a minimum rotation of reciprocation of the drill pipe to operate the tools therein, so as to keep the well blowout preventers closed during the majority of the operation. So-called annuls pressure responsive Donnelly tools have been developed, which tools operate responsive to pressure changes in annuls between the testing string and the well bore casing. number of these annuls pressure responsive tools are disclosed in the following patents assigned to the assignee of the present invention. For example, testing valves are disclosed in US. Patent Nos. aye, aye, 3,976,136, 3,964,544, 4,144,937/ 4,422,506, and 4,429,748. Circulation valves are disclosed in US. Patent Nos. 3,850,250, 3,970,147, 4,113,012, 4,324,293 and I
4,355,685. It is also known to operate a tool to take a sample of formation fluid with annuls pressure, as disclosed in US. Patent Nosy RYE 29,562 and 4,063,593. Moreover, tools which combine multiple functions have also been developed, as disclosed in the aforesaid RYE 29,562 (testing and sampling) and US. Patent Nos. 4,064,937, 4,270,610 and 4,311,197 (circulating and sampling While many of the aforesaid tools provide a biasing source comprising an inert gas under pressure to oppose annuls pressure, it is also known to employ a compressible fluid, such as silicone oil, as disk closed in US. Patent Nos. 4,109,724, 4,109,725, 4,444,268 and 4,448,254. Moreover, the use of a compressed gas in combination with a fluid, such as oil, is disclosed in US.
Patent Nos. 4,422,506 and 4,4~9,748.
There exist other testing, circulating and sampling tools and the like which operate in response to annuls pressure, as disclosed in US. Pa-tent Nos. RYE 29,~38, 3,796,261, 3,823,773, 3,901,314, 3,986,554 and 4,403,659, assigned to Schlumberger Technology Corporation; US. Patent Nos. 4,105,075 and 4,125,165, assigned to Baker International Corporation; US. Patent No. ~l,341,266, assigned to Lyres, Irlc.; and US. Patent Nos. 3,891,033 and 4,399,870, assigned to Lucy Tool Company.
Drill pipe tester vivace which operate responsive to pipe string manipulation are disclosed in US. patent twos.
~1,295,361, 4,319,633, ~,319,634 and ~,421,172, all assigned to the assignee of the present invention.
While the tools of the prior art are diverse in design, they suffer from a namer of deficiencies in actual operation. First, while several functions have been combined I
into one tool in some instances, the operation thereof depends upon use of multiple pressures, shearing ox pins, or pressure variation both inside and outside the pipe string.
Inability to maintain precise pressure levels hampers the use of some of these tools, while the use of shear pins prevents further operation of other tools after the pins have sheared.
Many prior art tools employing therein a fluid such as oil utilize fluid meterincj means such as flow restructures of a -jet type exemplified by the Lee Disco Jet, described in US.
Pa-tent No. 3,323,550, in conjunction with check valves. Such metering means and check valves are susceptible to clogging and often fail to operate properly if the fluid becomes contaminated or is of a low quality to begin with, a common occurrence in many remote areas of the world where these tools are operated. In addition, the use of fluid metering means requires an inordinate amount of time to cycle -the prior art tools, thus prolonging time on the job side and cost to the well operator. Furthermore, temperature increases or decreases in the well bore from ambient surface temperatures change viscosity in the oils employed in these tools, thus affectincJ the performance of fluid metering means arid altering tool cycling time. A further disadvantage resides with those tools utilizing oil, water or other liquicts as an expetldable fluid, as they are limited in the number of times they can be cycled Donnelly.
Finally, even thollgh some attempts have been made to combine multiple functions in a single tool, there has heretofore been no successful combination of more than Tao functions in a Sweeney tool.
I
SUMMARY OF THE INVENTION
In contrast to the prior art, the present invention comprises a Donnelly tool which is capable of performing in different modes of operation as a drill pipe tester valve, a circulation valve and a formation tester valve, as well as providing its operator with the ability to displace fluids in the pipe string above the tool with nitrogen or another gas prior to testing or retesting. This latter function is a valuable advantage in testing of gas formations or other wear or low pressure formations which may not flow when subjected to a large hydrostatic head or which may even be damaged by the weight of fluid in the string when the formation tester valve is opened.
The tool of the present invention is operated by a ball and slot type ratchet mechanism which provides -the desired opening and closing responsive to a series of annuls pressure increases and decreases of a drill pipe tester/
formation tester valve, a circulation valve and a nitrogen displacement valve, as well as changing between the modes of tool operation in which each of these valves function. More-over, the opening and closing as well as chanting between tool modes is effected without requiring the accurate monk-toning of pressure levels such as is necessary with tools that employ multiple pressure levels above a reference level or both pipe string and annuls pressures. The various tool modes are mutually exclusive that is to say, only one mode is operative at a time to ensure, for example, that the air-culation valve and tester valve cannot operate at the same time. In addition, the tool of the present invention is not limited to a given number of cycles in an of its modes, unlike prior art tools which employ shear pins or expendable fluids.
Further advantages over prior art tools include elimination of the need for a bypass below the tool since the design of the present invention precludes any operation of the circulating valve due to internal string pressure, including formation pressure from below the tool or acidizing or fracturing pressure from above applied to the formation.
Conversely, circulating fluid under pressure is positively isolated from the formation below, due to the aforesaid "lock-out" feature which precludes opening of the -tester valve in conjunction with the circulation valve. A further advantage of the circulation mode is the ability to circulate in either direction, so as to be able to spot chemicals or other fluids directly into the testing swing bore from the surface, and then open the tester valve to treat the for motion therewith. Also, pumping cold fluid through the tool will not prevent it from operating.
In addition to the advantages enumerated above, the present inventiorl includes a novel and unobvious operating mechanism for fluid dispkFtcement in the tool which avoids the use of the slow restructures and check valves of the prior art, such mechanism having utility in a wide variety OX
cleanly tools, which employ pressure changes us a power source, end therefore not being so limited to thy wool disk closed herein. Elimination ox a fluid metering system Erectly ~2;~3~
reduces tool cycling time and avoids the effects of viscosity changes in the metered fluid, as well as providing enhanced reliability. Another portion of -the operating mechanism of the present invention includes a non-rotating ratchet sleeve end a rotating ball follower which enhances the reciprocation of the operating mandrel of the tool as disclosed, but which is also not so limited to that particular tool, having utility in other Donnelly tools as well.
It should be noted that the tool as disclosed is lo not limited to the four-mode (drill pipe tester, formation tester, circulation valve, nitrogen displacement valve) operation format. It may be employed in conjunction with another, independently actuated formation tester valve there-below, and substitute an alternative ratchet slot program to operate in a three-mode (drill pipe tester, circulation valve, nitrogen displacement valve) format, or in a two-mode (circulation valve, nitrogen displacement valve) format.
BRIEF DESCRIPTION OF THE DRAWINGS
The present invention will be more fully understood by a review of the following detailed description of the preferred embodiment thereof, in conjunction with the accom-paying drawings, wherein:
FIG. l provides a schematic vertically sectioned view of a representative offshore platform from which testing may be conducted and illustrates a formation testing string or tool assembly in a submerged well bore at the lower end of a string of drill pipe which extends upward to the platform.
FIG. AYE comprise a vertical half section of the tool of the present invention in a formation testing mode.
So FITS. AYE comprise a vertical half-section of the -tool of the present invention in a drill pipe -testing mode.
FIGS. AYE comprise a vertical half-section of the tool of the present invention in a nitrogen displacement mode, ERGS AYE comprise a vertical half-section of the tool of the present invention in a circulating mode.
FIG. 6 comprises a development of the slot design employed in the preferred embodiment of the tool of the lo present invention.
FIGS. PA and 7B comprise an enlarged section of an alternative embodiment of the nitroc,7en displacement valve of the present invention.
FIGS, 8, 9 and lo comprise alternative slot designs which may be employed to alter the mode-changing sequence in the tool of the present invention, DETAILED DESCRIPTION OF THE PREFERRED
EMBODIMENT OF THE INVENTION
Referring to FIG, l, the present invention is shown schematically incorporated in a testing string deployed in an ocher oil or gas jell, Platform 2 is shown positioned over a submerged oil or gas well bore 4 located in the sea floor it Wylie bore penetrating potential producing formcttion 8.
Well bore 4 is shown to be fined with steel casing lo, which is cemented islet place. A subset conduit 12 extends from the deck lo of platform 2 into a subset Waldo 16, which includes blowout preventer 18 therein. Platfornt 2 carries a derrick 20 thereon, as well as a hoisting apparatus 22, net a pump I which communicates with the well bore 4 via collateral conduit 26, which extends below blackout preventer I
353~
A testing string 30 is shown disposed in well bore I, with blowout preventer 18 closed thereabout. Testing string 30 includes upper drill pipe string 32 which extends downward from platform 2 to Waldo 16, whereat is located hydraulically operated "test -tree" 34, below which extends intermediate pipe string 36. Slip join-t 38 may be included in stripy 36 to compensate for vertical motion imparted to platform 2 by wave action slip join-t 38 may be similar -to thaw disclosed in So Patent No. 3,354,950 to Hyde. Below slip joint 38, intermediate string 36 extends downwardly to multi-mode testing tool 50 of the present invention. Below combination tool 50 is lower pipe string 40, extending to tubing seal assembly 42, which stabs into packer I When set, packer 44 isolates upper well bore annuls 46 from lower well bore annuls 48. Packer 44 may be any suitable packer well known in the art, such as, for example, a waker Oil Tool Model D packer, an Otis Engineering Corporation Type W
packer, or Halliburton Services SHOP, RUTS or EN DRYWALL SO
packers Tubing seal assembly 42 permits testing string 30 to communicate with lower well bore 48 through perforated tail pipe 52. In this manner, formation luckless from potential producing formation 8 may enter lower well bore 48 through the perforations 54 in casing 10, and be routed into testing string 30.
After packer I is set in well bore 4, formation test controlling the flow of fluid from potential pro~EucincJ
eorrnation 8 through testing string 30 may be conducted using variations in pressure effected in upper annuls 46 by pump Al arid control conduit 26, with associated relies valves snot shown). Prior to thy actual test, Herr, the pressure :~2~3~
integrity of testing string 30 may be tested with the valve hall of the multi-mode tool closed in the tool's drill pipe tester mode. Tool 50 may be run into well bore 4 in its drill pipe tester mode, or it may be run in its circulation valve mode to automatically fill with fluid, and be cycled to its drill pipe mode thereafter. Formation pressure, temperature and recovery time may be measured during the flow test through the use of instruments incorporated in testing string 30 as known in the art as the ball valve in tool 50 of the I present invention is opened and closed in its formation -tester valve mode. Such instruments are well known in the art, and include both Bourbon -tube-type mechanical gauzes electronic memory gauges, and sensors run on wire line prom platform 2 inside testing string 30 prior to the test. If the formation to ye tested is suspected to ye weak and easily damageable by the hydrostatic head of fluid in testing string 30, tool 50 may be cycled to its displacement mode and nitrogen or other inert gas under pressure employed to disk place fluids from the string prior to testing or retesting.
It may also be desirable to treat the formation 8 in conjunction with the testing program while testincl string 30 is in place. Such a treating program is conducted by pUmpincJ various chemicals end other materials down the interior of testing string 30 at a pressure sufficient to force tune chemicals and other materials into the formation, and to possibly fracture the formation. Of course, the chemicals, materials and pressures employed will vary clependirlg on the formation characteristics and the desired changes thought to be elective in enhancing formation productivity. In this manner it is possible to conduct a 9 _ ~.ZZ~53;~
testing program, treat the formation and a second testing program to determine treatment effectiveness without removal of testing string 30. If desired, treating chemicals may be spotted in-to testing string 30 from the surface by placing tool 50 in its circulation valve mode, and displacing string fluids into the annuls prior to opening the valve ball in tool 50.
At -the end of the testing and treating programs, the circulation valve mode of tool 50 is employed, the circus lotion viva opened and formation fluids, chemicals and other injected materials in testing string 30 are circulated from the interior of testing string 30 into upper annuls 46 using a clean fluid, packer 44 is released (ox tubing seal 42 with-drawn if packer 44 is to remain in place) and testing string 30 withdrawn from well bore 4.
Referring to FIGS. AYE, tool 50 is shown in section, commencing at the top of the tool with upper adapter 100 having threads 102 therein at its upper end, whereby tool 50 is secured to drill pipe in the testing string. Upper acklpter 100 it secured to nitrogen valve housing 104 air:
threaded connection 106, housing 104 containing a valve assembly (not shown), such as is well known in the art, yin lateral bore 108 in the Lyle thereof, from which extends clownwarctly Longitudinal nitrogen charging channel lo.
Valve housirlg loll is secured by threaded connectiorl ll2 at its outer lower end to tubular pressure case 1l4, and ; by threaded collection 116 at its inner lower end to gay chamber mandrel lid, case 114 and mandrel 118 clcfi.iing pressurized gas chamber 120 end upper oil chamber l22, the two Boone separated by floatincJ annular piston 12~1.
- Lo -I I
The upper end of oil channel coupling 126 extends between case 114 and gas chamber mandrel 118, and is secured to the lower end of case 114 at threaded connection 128. A
plurality of longitudinal oil channels 130 (one shown) extend from the upper end of coupling 126 to the lower end thereof. Radially drilled oil fill ports 13~ extend from the exterior of tool 50, intersecting channels 130 and are closed with plugs 13~. Annular shoulder 136 extends radially inward from inner wall 138 of coupling 126. The lower end of coupling 126, including annular overshot 127, is secured at threaded connection 140 to the upper end of ratchet case 142, through which oil fill ports 1~4 extend at annular shoulder 146, being closed by plugs 148. At the lower end of ratchet case 142 are additional oil fill ports 150 closed by plugs 152 and open pressure ports 15~.
Ratchet slot mandrel 156 extends upward within the lower end of oil channel coupling 126. Annular ratchet chamber 158 is defined between mandrel 156 and case 142. The upper exterior 160 of mandrel 156 is of substantially uniform diameter, while the lower exterior 162 is of greater diameter so as to provide sufficient wall thickness for ratchet slots 16~. There are preferably two such ratchet slots 16~ of the configuration shown in FIG. 6 extending about the exterior of ratchet slot mandrel 156.
Ball sleeve assembly 166 surrounds ratchet slot mandrel 156, and comprises upper sleeve 168 including radially outwardly extending annular shoulder 170 having annular piston seat 17~ thereon. Below shoulder 170, ratchet piston support surface 173 extends to the lower end of upper sleeve 168, which is overshot by the upper end of lower ~.~2~353Z
sleeve 174 having annular piston seat 176 thereon, and to which is secured at threaded connection 178. Ball sleeve 180 is disposed at the bottom of lower sleeve 174, and is secured thereto at swivel bearing race 182 by a plurality of bearings lay. Two ratchet balls 186 each extend into a ball seat 188 on diametrically opposite sides of ball sleeve 180 and into a ratchet slot 164 of semicircular cross-section. Due to this structure when balls 186 follow the path of slots 164, ball sleeve 180 rotates with respect to lower sleeve 174, the remainder of ball sleeve assembly 166 does not rotate, and only longitudinal movement is transmitted to ratchet mandrel 156 by balls 186.
Upper annular ratchet piston 190 and lower annular ratchet piston 192 ride on piston support surface 173 on upper sleeve 168, coil spring 194 being disposed there-between. Upper ratchet piston 190 carries radial sealing surface 196 on its upper end, while lower ratchet piston 192 carries radial sealing surface 198 on its lower end.
The lower end 200 of ratchet slot mandrel 1~6 is secured at threaded connection 202 to extension mandrel 204 having relief ports 208 extending there through. Annular lower oil chamber 210 is defined by ratchet case 142 and extension mandrel 204. annular floating piston 212 slidingly seals the bottom of lower oil chamber 210 and divides it from well fluid chamber 21q into which pressure ports 154 opens. The lower end of ratchet case 142 is secured at threaded connect -lion 218, to extension case 216, which surrounds extension mandrel 204.
I
Circulation-displacement housing 220 is threaded at 222 to extension case 216, and possesses a plurality of circumferential spaced radially extending circulation ports 224 as well as a plurality of nitrogen displacement ports 226 extending through the wall -thereof.
Circulation valve sleeve 228 is threaded to extension mandrel 204 a-t 230. Valve apertures 232 extend through the wall of sleeve 228, and are isolated from circus lotion ports 224 by annular seal 234, which is disposed in seal recess 236 formed by the junction of circulation valve sleeve 228 with displacement valve sleeve 238, the two being threaded together at 240. The exterior of displacement valve sleeve 238 carries thereon downwardly facing radially extending annular shoulder 242 thereon, against whiz}- bears displacement spring 244. The lower exterior of displacement valve sleeve 238 is defined by displacement piston surface 246 upon which sliding annular displacement piston 248 rides.
Annular valve surface 250 of piston 248, and seats on elastomeric valve seat 254. Nitrogen displacement apertures 256 extend through the wall of displacement valve sleeve 238.
Valve seat 254 is pinched between sleeve 238 and shoulder 257 of sleeve 238 and flange 258 of operating mandrel 260, which is secured to sleeve 238 at threaded connection 262.
Seal carrier 264 surrounds mandrel 260 and the junction of mandrel 260 with sleeve 238 and is secured to mandrel 260 at threaded connection ~65. Square cross-section annular seal 266 is carried on the exterior of mandrel 260 adjacent flange 258, and is secured in place the upper end of seal carrier 26~.
-~2Z~353~
Below seal carrier 264, mandrel 260 extends down-warmly to exterior annular recess 267, which separates annular shoulder 268 from the main body of mandrel 260.
Collect sleeve 270,. having collect fingers 272 extending upward therefrom, engages operating mandrel 260 through the accommodation of radially inwardly extending protuberances 274 by annular recess 267. As is readily noted in FIG. 2G~ protuberances 274 and the upper portions of lingers 272 are confined between the exterior of mandrel 260 Rand the interior of circulation-displacement housing OWE
At the lower end of collect sleeve 270, coupling 276 comprising flanges 278 and 280, with exterior annular recess 282 there between, grips coupling 284, comprising inwardly extending flanges 286 and 288 with interior recess 2g0 there-between, on each of two ball operating arms 292. Couplings 276 and 284 are maintained in engagement by their location in annular recess 296 between ball case 294, which is threaded at 2g5 to circulation-displacement housing 220, and ball housing 298. Ball housing 298 is of substantially tubular configuration, having an upper smaller diameter portion 300 and a lower, larger diameter portion 302 which has two windows 304 cut through the wall thereof to accommodate the inward protrusion of lugs 306 from each of the two ball operating arms 292. Windows 304 extend from shoulder 311 downward to shoulder 314 adjacent threaded connection 316 with ball support 340. On the exterior of the ball housing 298, two longitudinal channels location shown by arrow 30~3) of arcuate cross-section and circumferential aligned with windows 30~, extend from shoulder 31Q downward to shoulder 311. Ball operating arms 292, which are of substantially the same arcuate cross-section as channels 308 and lower portion 302 of ball housing 298, lie in channels 308 and across windows 304, and are maintained in place by the interior wall 318 of ball case 294 and the exterior of ball support 340.
The interior of ball housing 293 possesses upper annular seat recess 320, within which annular ball seat 322 is disposed, being biased downwardly against ball 330 by ring spring 324. Surface 326 of upper seat 322 comprises a metal sealing surface, which provides a sliding seal with the exterior 332 of valve ball 330.
Valve ball 330 includes a diametrical bore 334 there through, of substantially the same diameter as bore 328 of ball housing 298. Two lug recesses 336 extend from the exterior 332 ox valve ball 330 to bore 33~.
The upper end 342 of ball support 340 extends into ball housing 298, and carries lower ball seat recess 344 in which annular lower ball seat 346 is disposed. Lower ball seat 346 possesses arcuate metal sealing surface 348 which slidingly seals against the exterior 332 of valve ball 330.
when ball housing 298 is made up with ball support 340, upper and lower ball seat 322 and 346 are biased into sealing engagement with valve ball 330 by spring 324.
Exterior annular shoulder 350 on ball support 340 is contacted by the upper ends 352 ox splints 354 on the exterior ox ball case 294, whereby the assembly of ball houslllcJ 294, ball operatinc3 arms 292, valve ball 330, ball seats 322 and 3~6 and sprincJ 324 are maintained in position inside of ball case 294. Splints 354 encage splints 356 on 353~
the exterior of ball support 340, and thus rotation of the ball support 340 and ball housing 298 within ball case 298 is prevented.
Lower adapter 360 protrudes at its upper end 362 between ball case 298 and ball support 340, sealing there between, when made up with ball support 340 at threaded connection 364. The lower end of lower adapter 360 carries on its exterior threads 366 for maying up with portions of a test string below tool 50.
When valve ball 330 is in its open position, as shown in FIG. 2G, a "full open" bore 370 extends throughout tool 50, providing an unimpeded path for formation fluids and/or for perforating guns, wire line instrumentation, etc.
OPERATION OF THE PREFERRED EMBODIMENT
OF THE PRESENT INVENTION
.
Referring to FIGS. 1 through 6, operation of the combination tool 50 of the present invention is described hereafter.
As tool 50 is run into the well in testing string 30, it is normally in its drill pipe tester mode shown in FIGS. AYE, with ball 330 in its closed position, with ball bore 334 perpendicular to tool bore 370. In this position, circulation ports 224 are misaligned with circulation aver-lures 232, seal 234 preventing communication there between. In a similar fashion, nitrogen misplacement ports 226 are offset from displacemerlt apertures 256 and isolated therefrom by seal 266. With respect to FIG 6, balls 136 will be in positions "a" in slots 164 as tool 50 is run into the well bore.
As tool 50 travels down to the level of the for-motion 8 -to be tested, at which position packer 44 is set, floating piston 212 moves upward under hydrostatic pressure, pushing ball sleeve assembly 166 upward, and causing balls 186 to move to positions "b", which dyes not change tool modes or open any valves. A pressure integrity check of the testing string 30 above tool 50 may then be conducted before flow testing the formation.
In order to open valve ball 330 to conduct a flow test of a formation, pressure is increased in annuls 46 by pump 24, via control conduit 26. This increase in pressure is transmitted through pressure ports 154 into well fluid chamber 214, where it acts upon floating piston 212. Piston 212 in turn acts upon a fluid, such as silicone oil, in lower oil chamber 210, which communicates with ratchet chamber 158.
In ratchet chamber 158, the pressurized oil pushes anisette upper ratchet piston 190, the oil being prevented from by-passing piston 190 by the metal to metal seal of sealing surface 196 on piston seat 172. Piston 190 therefore pushes against shoulder 170 on upper sleeve 168, which in turn pulls lower sleeve 17~, hall sleeve 180 and balls 186 Upward in slots 164. In this manner, balls 186 are moved to positions c, which has no effect on tool operation as balls 186 do not shoulder on the ends of slots 164 in this position. The aforesaid feature is advantageous in that it permits pressuring of -the well bore annuls 46 to test the seal of packer 44 across the well bore 4 without opening valve ball 330. By way of elaboration, when piston 190 reaches overshot 127, it is restrained from further upward movement, but fluid continues to act on shoulder 170 of upper sleeve 168, spreading piston seat 172 from seating surface 196, breaking the seal and dumping fluid past upper sleeve 168 into oil channels 130 and upper oil chamber 122, which equalizes -the pressures on both sides of piston 190 and stops the movement of ball sleeve assembly 166 and of balls 186 in slots 164. As the length of toe slot is greater than the travel of the ball sleeve assembly, balls 186 stop short of the slot end. As annuls pressure is bled off, the pressurized nitrogen in chamber 120 pushes against floating piston 124, which pressure is transmitted through upper oil chamber 122, channels 130 and ratchet chamber 158 against lower ratchet piston 176. As ratchet piston 176 is biased against piston seat 176, a metal to metal seal is effected between radial sealing surface 198 and seat 176. Ball sleeve assembly 166 is therefore biased downwardly, ratchet balls 186 follR~ing the paths of slots 164 to position do, where they shoulder on the ends of the slots. Tool 50 is now in its formation tester valve mode as shown in FIGS. AYE, but with valve ball 330 closed. When lower ratchet piston 192 reaches annular shoulder 146 in its downward travel, fluid continues to act on ball sleeve assembly 166, spreading sealing surface l98 from seat 176. Fluid is thus dumped below ball sleeve assembly 166 and is thereby equalized, stopping the travel of ball sleeve assembly 166, bells 185 and ratchet mandrel 156.
When the well bore annuls I 5 again pressured, ball sleeve assembly 166 moves upward and balls 1~6 shoulder in slots 16~ at position of roving ratchet mandrel 156 upward, which pulls extensioEl mandrel 204, circulation valve sleeve 228, displacement. valve sleeve 238 and operatirlg mandrel I
upward. Opportune mandrel 260 pulls collect sleeve on upward, 353~, which pulls arms 292 and rotates valve ball 330, aligning ball bore 334 with tool bore 370, permitting the formation to flow into the testing string 30 above tool 50. Tool 50 is now in the tester valve mode shown in FIGS. AYE with valve ball 330 open. When annuls pressure is released, balls 186 shoulder at position do, and close valve ball 330, but tool 50 is still in the tester mode of FIGS. AYE. The process of pressuring and releasing pressure may be continued to open and close ball 330 to flow test the formation until balls 186 reach positions do.
A subsequent increase in annuls pressure will shoulder balls 186 momentarily on inclined edges aye before moving further along slots 164 past positions f but valve ball 330 will not open. When pressure is released again, balls 186 move downward and shoulder in positions f, moving ratchet mandrel 156 downward and tool 50 out of its formation tester mode and back into the nitrogen displacement mode of FIGS. AYE. As can readily be seen in Fig. OH, protuberances 274 on collect sleeve fingers 272 are disengaged from open-cling mandrel 260 in this mode, preventing rotation and no-opening of ball 330.
A subsequent increase and decrease of annuls pressure causes balls 186 to climb further in slots 164 past positions g, and then to push ratchet mandrel 156 downward, moving tool 50 to its circulation valve mode shown in ITS
AYE. fluid may be circulated into the testing string 30 from annuls 46 through circulation ports 224, which are aligned with circulation apertures 232, ball valve 330 in its closed position end nitrogen displacement ports 22~ offset prom apertures 256~ Fluid ma also ye circulated into annuls 46 3.2~3S32 from the testing string 30, as when it is desired to spot formation treatment chemicals into the string prior to an acidizing or fracturing operation. As may be easily observed in FIG. 5G, operating mandrel 156 has continued to travel downward within collect sleeve 270 but out of engagement with protuberances 274.
Subsequent pressure increases and decreases in the annuls will move balls 186 sequentially to positions hi, if, ho, it, and ho without changing -tool 50 prom its circulation mode, as balls 186 do not shoulder in slots 164. This provides a margin of safety against changing of tool modes due to inadvertent pressure cycling in -the annuls during circulation.
As annuls pressure is decreased after balls 186 reach positions ho, they will move downward past positions j, whereupon a subsequent annuls pressure increase will shoulder balls 186 in positions j, moving ratchet mandrel 156 upward and tool 50 back into its nitrogen displacement mode of FIGS. AYE. It treatment chemicals have no-t been spotted in the string, and if it is desired to displace fluid out of the testing string 30 prior to a further test, as where the formation has not flowed initially due to hydrostatic head ox fluid in the string, nitrogen may be introduced into the testing string 30 under pressure. In this mode, valve ball 330 is closed and circulation ports 22~ offset from apertures 232, but nitrogen displacement ports 226 are aligned with apertures 2~6. The pressurized nitrogen isle act upon disk placement piston 248, moving it away from seat 254, and permit fluid in the siring. to exit into the well bore annuls. When pressure it reduced in the string, annuls ~.'2~Z~3S3;~
pressure outside tool 50 will act upon the upper end of disk placement piston 248 through circulation ports 22~, and firmly press valve surface 250 against seat 254, preventing reentry of fluid into the string.
As in the circulation mode, several subsequent increases and decreases in annuls pressure will move balls 186 in slots 164, but will not change the mode of tool 50. As pressure is decreased and increased sequentially when balls are in positions j, they move to positions Al, 11, k2 and 12.
When pressure is again decreased with balls 1~6 in position 12, they will move downward in slots 16~ past position m, where a subsequent increase will shoulder balls 186 out on slots 164 in positions m, changing tool mode to the drill pipe tester modify FIGS. AYE, offsetting nitrogen disk placement pouts and apertures, leaving circulation ports and apertures offset, and leaving valve ball 330 closed.
further decrease in pressure will return balls 186 to post-lions a, and the operator may begin another cycle of tool 50, such as to treat the formation and retest it after the treat-mint, or test it with the string unloaded of fluid.
By way of further explanation of the mode changing and operating sequence of tool 50, the reader should note that the tool only changes mode when balls 1~6 shoulder at specific foreshortened positions on slot 164 during cycling of the tool. For example, tool 50 changes mode a positions do, do, f, g, j end m. Four mode changes are effected by annuls pressure decrease, and two by an increase. The pressure increases which shoulder balls 1~6 in positions I
through en do not produce a mode change because balls 1~6 travel within a restricted longitudinal range limited ho the I
dumping of the operating fluid in the tool by pistons 190 and 192, and the configuration of the slots 164 from positions of through en does not permit balls 186 to climb in slots 16~ to change tool modes.
OPERATION OF A SECOND PREFERRED EMBODIMENT OF
THE PRESENT INVENTION
As has previously been noted, tool 50 of the present invention may be changed to operate in a three-mode sequence as a drill pipe testes, circulation valve and nitrogen displacement valve in conjunction with a separate tester valve there below in the string by merely removing ratchet mandrel 156 and inserting another mandrel 1~6' having a different slot program 164' therein. Such a mandrel slot program 16~' is shown in FIG. 8. In all respects other than substitution of mandrel 156' for mandrel 156, tool 50 remains structurally the same even though its modes of operation have been altered.
With slot 164', tool So is run into the well bore in its drill pipe tester mode with balls 186 in positions a as shown in ERG. 8 and tool 50 in the mode shown in FIGS.
AYE. As tool 50 travels down the well bore, hydrostatic nulls pressure will move balls 186 to position b. As village ball 330 remains closed, an integrity test of the drill pipe may be conducted. The first increase in annuls pressure subsequent to the drill pipe test will move balls 186 to positions c, which will not change tool mode, And a subsequent decrease and increase will shoulder balls on slot 16~' at position d, which will rotate alluvia ball 330 to an open position, aligning bore 334 with tool bore 370 as shown in FIGS. AYE. This same pressure increase will haze opened ~Z~2~353~
the ball of the tester valve there below, which may be a valve such as are disclosed in US. Patent No 3,964,544, 3,976,136, 4,422,506, 4,429,748, as well as others known in the art. The formation then flows through the tester valve and tool 50 during the test. When annuls pressure is de-creased to close the tester valve, the decrease will move balls 186 to positions of,. which will not close valve ball 330 because balls 186 do not shoulder on slots 164'.
Subsequent pressure increases and decreases to flow test the well via the tester valve will move balls 186 sequentially to P I en' f2~ eye f3 and en, during which valve ball 330 of tool 50 will remain open. During the next subsequent annuls pressure increase when in position en, balls 186 will climb in slot 164' past positions g, valve ball remanning open. When annuls pressure is relieved, however, balls 186 will shoulder in positions g and move ratchet mandrel 1S6' downward, closing valve ball 330 and returning tool 50 to its drill pipe tester mode shown in FIGS. AYE.
Another increase and decrease in annuls pressure will move balls 186 to shoulder in positions h, changing tool to the nitrogen displacement mode of FIGS. AYE. A second increase/decrease pressure cycle will move balls 186 to positions i and tool 50 to the circulation mode of FIGS.
ASSAY.
Subsequent increases and decreases in annuls pressure will ratchet balls 186 through positions Jo it it it, Jo, and down past I without changing tool mod, after which an increase will shoulder balls 1~36 in positions Al, changing tool I to the neutron displacement mode ox FOGS.
AYE.
I Z
Further annuls pressure cycling in decrease/
increase sequence will move balls 186 to positions 11, k2, 12, k3 and down past positions m without changing tool mode.
A subsequent pressure increase will shoulder balls 186 in positions m and change tool 50 to its drill pipe tester mode of FIGS. AYE. Further pressure cycling of the annuls will begin another tool cycle.
As noted with respect to slot 164, tool 50 only changes mode when balls 186 shoulder in foreshortened paths in the slot. In slot 164' for example, tool mode changes only in ball positions d, g, h, if, Al, and m. In all other instances, balls 186 merely travel slots 164' with no effect on tool operation.
ALTERNATIVE EMBODIMENTS OF THE
PRESENT INVENTION
A
it is also possible to reprogram tool So of the present invention to effect modes of operation other than those disclosed with respect to the first and second preferred embodiments.
For example, referring to FIG. 9, the program of slot 164" is shown. Using mandrel 156'l with slot 164", tool 50 is run into the well bore in its drill pipe tester mode of FIGS. AYE, with balls 186 in positions a in slots 164.
Going Donnelly, balms 186 will be forced upward to positions b by hydrostatic pressure in the annuls. A drill pipe integrity test may be conducted when tool I reaches the jest level in the well bore.
After the packer is set, the formation may be flow tested by raising annuls pressure, lowering it and raising I it again, which moves balls up through portions c, down past - Al -~2~53~2 portions do, and up to do whereat balls 186 shoulder and open valve ball 330, tool 50 being in the tester valve mode of FIGS. AYE. A subsequent decrease in annuls pressure will move balls 186 to position of, which will retain valve ball 330 in an open position. Another increase/decrease cycle will close valve ball 330 due to shouldering of balls 186 in positions if and downward movement of ratchet mandrel 156.
Another increase/decrease cycle will result in ball movement to positions go, and down past do, with valve ball 330 remaining closed. The next increase/decrease opens valve ball 330 when balls 186 shoulder in positions do, and leave valve ball 330 open when balls 186 travel to positions en. The following increase/decrease shoulders balls 186 in positions f2 as annuls pressure is relieved, closing valve ball 330. A
further increase/decrease moves balls 186 to position go an back down below do, after which the next subsequent increase/decrease shoulders balls 186 in positions do, opening valve ball 330 and leaving it open as balls 186 land at position en.
To continue the tool cycle, an annuls pressure increase/decrease moves balls 186 to f3, closing valve ball 330. Balls 186 climb slots 164"' with the next lncrease/decrease to position h, whereat tool 50 is shifted to its nitrogen displacement mode of FOGS. AYE, and then to its circulation mode of FIGS. AYE when annuls pressure is again cycled and balls 186 shoulder in positions it.
The next three increase/decrease cycles in annuls pressure will move balls 186 through positions if, it, Jo, it, Jo and back down past position Al. During this travel, balls 186 do not shoulder, and the tool 50 does not change mode. However, the next subsequent increase in pressure will shoulder balls 186 in position Al, change tool mode to the nitrogen displacement mode of FIGS. AYE.
The next two decrease/increase pressure cycles move balls 186 through positions 11, k2, 12 and k3 without change in tool mode. During the following decrease/increase cycle, however the tool is moved back to its drill pipe test mode of FIGS. AYE when balls 181 move downward below positions on the decrease and then shoulder as pressure is increased. When annuls pressure is next decreased, balls 186 move back to positions a for commencement of a new tool cycle.
As was noted with respect to the previous operating mandrels 156 and 1S6' mandrel 156`' does not move longitu-finally to operate valve hall 330 and to change tool modes unless balls 186 shoulder in foreshortened legs of slots 164". In slots 164", only positions do, f3, h, if, Al, end To produce a change of mode. Positions do, if, do, En, do and f3, however, all serve to open and close, respectively valve ball 330.
With the slot program employed in slot 16~1", the test operator must positively pressure the annuls and then relieve pressure for valve ball 330 to move from a closed to an open position and vice-versa, which feature prevents a shutoff in the middle of a flow test if annuls pressure is reduced inadvertently. Furthermore, valve ball 330 may he left open after the formation test and circulatioTI, to let ~estincJ string 30 drain of fluid as it is removed from well bore 9.
I
Another embodiment of the present invention may be effected utilizing yet another slot program, illustrated in FIG. 10 as slot 164"' on mandrel 156"'. With slots 164"', tool 50 is restricted to a two-mode operation, circulation valve, which would be preferred in some areas ox the world which do not conduct drill pipe tests prior to flow testing the well, and which use a separate tester valve below tool 50.
With slots 164"', ratchet balls 186 commence in possessions a, and move to be as tool 50 travels down the well bore. Valve ball 330 is open. A first annuls pressure increase after packer 44 is set will result in ball movement to positions at, and subsequent decrease/increase cycling will move balls 186 through positions do, c2, do and C3 to do. The next three increase/decrease pressure cycles will result in balls 186 climbing slots 164"' to positions e, which closes valve ball 330; positions f, which places tool 50 in its displacement valve made; and position go, which places tool 50 in its circulation valve mode The next three 20increase/decrease pressure cycles will result in free ball movement through positions hi, go, ho, go and ho past if, without moving tool 50 from its circulation valve mode.
However, a subsequent increase will change tool mode to disk placement valve, as balls 186 shoulder in positions il. This mode is maintained through the next two decrease increase cycles with tree ball travel. The Nat decrease increase cycle then moves balls 186 to shoulder in positions k, which offsets both displacement ports 226 from displacemerlt aver-lures 256 and circulation ports 224 from circulation aver-Tories 232 while leaving valve ball 330 closed. The Nikko - I -3S3~
subsequent decrease/increase cycle will again open valve ball 330 with balls 186 in positions 1, and an annuls pressure decrease will place balls back in positions a for another tool cycle. In slots 164"', balls 186 shoulder in positions en I go k and 1-ALTERNATIVE EMBODIMENT OF TOE DISPLACEMENT VALVE
OF THE PRESENT INVENTION
FIGS. PA and 7B illustrate an alternative construe-lion for a nitrogen displacement valve assembly which may be employed in tool 50. Valve assembly 400 includes an outer circulation-displacement housing 220' with slightly longer spacing between circulation ports 224 and displacement aver-lures 234 than in standard housing 220. At its upper end, housing 220' is secured at threaded connection 222 to extension case 216, while at its lower end (not shown) it is secured to ball case 294. Within tool 50, extension mandrel 204 is secured at threaded connection 230 to circulation valve sleeve 228, through which circulation apertures 23Z
extend. Sleeve 228 is threaded to displacement valve sleeve 238', seal 234 being maintained in an annular recess 236 there between to isolate circulation apertures 232 from circus lotion ports 224.
On the exterior of displacement valve sleeve 238' lie annular marker grooves 420 three grooves), 422 (two grooves) and 424 ( one groove), the purpose of which will be explained hereafter. Below the marker grooves displacement apertures 256 e~tencl through the wall of sleeve 238' adjacent obliquely inclined annular wall 416, which it a part of dip-placement assembly 400.
- I -lo it Flapper mandrel 406 slides on the exterior of sleeve 238' below wall 416, and is restricted in its longitu-dial travel by the abutment of elastomeric seal 414 against wall 416 at its upper extent, and by the abutment of shoulder 408 against stop 404 extending upward from shoulder 402 on operating mandrel 260'. Stops 404 prevent pressure locking of shoulder 408 to shoulder 402. Seal 266 is maintained in a recess between annular shoulder 258' on mandrel 260' and seal carrier 264, which surrounds threaded connection 262 between sleeve 238' and operating mandrel 260', and is itself secured to operating mandrel 260' at threaded connection 265.
Flapper mandrel 406 carries thereon a plurality of frustoconical valve flappers 412 thereon, which are bonded to mandrel 406 adjacent annular shoulders 410.
Displacement assembly 400 is placed in its opera-live mode in the same fashion as the displacement mode of tool 50 in FIGS. 2-5, that is by longitudinally moving the internal assembly connected to ratchet mandrel 156 through the interaction of balls 186 in slots 164. However, unlike displacement piston 248 which is spring-biased toward a closed position against seat 25~ (FIGS. 2E-F, 3E-F) and is moved therefrom by nitrogen slowing under pressure throllgh apertures 256 (FIGS. 4E-F), mandrel 406 operates when placed adjacent displacement ports 226 FIGS. AHAB) throuc3h downward movement against stops 404 followed by collapse of flappers 412 against mandrel 406 to permit exit through ports 226 of -the fluid in the string and the pressurized nitrogen impelling it into the well bore annuls.
~1~2;~ 32 If pressure is removed from the bore 370 of tool 50, the hydrostatic head (and pressure) in the annuls will expand flappers 412 against circulation-displacement housing 220' and move mandrel 406 upward against wall 416, whereon elastomeric seal 414 will seat, preventing reentry of annuls fluids into bore 370.
An added feature-of assembly 400 is the ease of identification of tool mode through the use of marker grooves 420, 422 and 424. For example, when tool 50 is in its circus lotion mode, circulation ports 224 will be aligned with air-culation apertures 232 and no grooves will be visible. When tool 50 is in its displacement mode (FIGS. AHAB, grooves 420 will be visible. When valve ball 330 is closed, grooves 422 will be visible, and when valve ball 330 is open, groove 420 will be visible. With knowledge of which ratchet mandrel is employed in tool 50 and the initial portion desired, the tool will then be easily able to ensure placement of tool 50 in its proper mode for running into the well bore.
It is thus apparent that a novel and unobvious multi-mode testing tool has been developed, which further includes a novel and unobvious operating mechanism and valves therein. It will be readily apparent to one of ordinary skill in the art that numerous additions, deletions and modify-cations may be made to the invention as disclosed in its preferred and alternative embodiments as disclosed herein.
For example, tool 50 might employ an all-oil operating biasing mechanism such as is disclosed in US. Patent Nos.
4,109,724, 9,109,7~5, 4,444,268 and 4,4~l8,254; the nitrogen displacement valve might be placed above the circulation 3Q valve in the tool; alternative pressure-responsive check -ISLE
valve designs might be employed as displacement valves;
Belleville or other springs might be substituted for the coil springs shown in tool 50; the operating mechanism of the tool, including nitrogen and/or oil chambers, the ratchet mandrel and the ball sleeve assembly could be placed at the bottom of the tool or between the ends thereof; the ratchet balls could be seated in recesses on a mandrel and a rotating ratchet sleeve with slots cut on the interior thereon might be employed there around and joined by swivel means to a sleeve assembly carrying annular pistons 190 and 192 thereon;
a ratchet sleeve might be rotatable mounted about a separate mandrel and ratchet balls mounted in a non-rotating sleeve assembly thereabout; a sleeve-t~pe valve such as is disclosed in I Patent RYE 29,562 might be utilized to close bore 370 through tool 50 in lieu of a ball velvet an annular sample chamber might be added to tool 50 such as is also disclosed in the aforesaid US. Patent I 29,5~2; a second valve ball might be included longitudinally spaced from valve ball 330 and secured to operating mandrel 260 to form a ball-type sampler having a mechanism Seymour to those disclosed in US.
Patent Nos. 4,06~,937, ~,270,610 and ~,311,197; the valve ball 330 could be placed at the top of the tool and employed for drill pipe test purposes only with another tester valve run below the tool, as has been heretofore suggested; an annular piston having a longitudinal channel therein with a resiliently biased check valve closure member and valve seats at each end thereof may be substituted for the piston sleeve and pistons of the preferred embodiment, using for stop meal-s a pin or rod adapted to push the check valve closure member back from its seat aye each limit ox piston travel to dump ~.~22~53~2 fluid therapist. These and other changes may be effected without departing from the spirit and scope of the claimed nvent1on.
This application is a divisional of Canadian Patent Application No. 479,772, filed February 20, 1935.
Well testing and stimulation operations are commonly conducted on oil and gas wells in order to determine production potential and -to enhance same if possible. In flow testing a well, a tester valve is lowered into the well on a string of drill pipe above a packer. After the packer is set, the tester valve is opened and closed periodically to determine formation flow, pressure, and rapidity of pressure recovery Also generally included in a testing string are a drill pipe tester valve and a circulation valve above the tester valve, -the former to permit testing the pressure integrity of the string prior to conducting the test, and the latter to permit the circulation of formation fluids out of the string after the test is completed.
It is desirable, particularly when conducting tests on offshore wells, to employ a testing string which requires a minimum rotation of reciprocation of the drill pipe to operate the tools therein, so as to keep the well blowout preventers closed during the majority of the operation. So-called annuls pressure responsive Donnelly tools have been developed, which tools operate responsive to pressure changes in annuls between the testing string and the well bore casing. number of these annuls pressure responsive tools are disclosed in the following patents assigned to the assignee of the present invention. For example, testing valves are disclosed in US. Patent Nos. aye, aye, 3,976,136, 3,964,544, 4,144,937/ 4,422,506, and 4,429,748. Circulation valves are disclosed in US. Patent Nos. 3,850,250, 3,970,147, 4,113,012, 4,324,293 and I
4,355,685. It is also known to operate a tool to take a sample of formation fluid with annuls pressure, as disclosed in US. Patent Nosy RYE 29,562 and 4,063,593. Moreover, tools which combine multiple functions have also been developed, as disclosed in the aforesaid RYE 29,562 (testing and sampling) and US. Patent Nos. 4,064,937, 4,270,610 and 4,311,197 (circulating and sampling While many of the aforesaid tools provide a biasing source comprising an inert gas under pressure to oppose annuls pressure, it is also known to employ a compressible fluid, such as silicone oil, as disk closed in US. Patent Nos. 4,109,724, 4,109,725, 4,444,268 and 4,448,254. Moreover, the use of a compressed gas in combination with a fluid, such as oil, is disclosed in US.
Patent Nos. 4,422,506 and 4,4~9,748.
There exist other testing, circulating and sampling tools and the like which operate in response to annuls pressure, as disclosed in US. Pa-tent Nos. RYE 29,~38, 3,796,261, 3,823,773, 3,901,314, 3,986,554 and 4,403,659, assigned to Schlumberger Technology Corporation; US. Patent Nos. 4,105,075 and 4,125,165, assigned to Baker International Corporation; US. Patent No. ~l,341,266, assigned to Lyres, Irlc.; and US. Patent Nos. 3,891,033 and 4,399,870, assigned to Lucy Tool Company.
Drill pipe tester vivace which operate responsive to pipe string manipulation are disclosed in US. patent twos.
~1,295,361, 4,319,633, ~,319,634 and ~,421,172, all assigned to the assignee of the present invention.
While the tools of the prior art are diverse in design, they suffer from a namer of deficiencies in actual operation. First, while several functions have been combined I
into one tool in some instances, the operation thereof depends upon use of multiple pressures, shearing ox pins, or pressure variation both inside and outside the pipe string.
Inability to maintain precise pressure levels hampers the use of some of these tools, while the use of shear pins prevents further operation of other tools after the pins have sheared.
Many prior art tools employing therein a fluid such as oil utilize fluid meterincj means such as flow restructures of a -jet type exemplified by the Lee Disco Jet, described in US.
Pa-tent No. 3,323,550, in conjunction with check valves. Such metering means and check valves are susceptible to clogging and often fail to operate properly if the fluid becomes contaminated or is of a low quality to begin with, a common occurrence in many remote areas of the world where these tools are operated. In addition, the use of fluid metering means requires an inordinate amount of time to cycle -the prior art tools, thus prolonging time on the job side and cost to the well operator. Furthermore, temperature increases or decreases in the well bore from ambient surface temperatures change viscosity in the oils employed in these tools, thus affectincJ the performance of fluid metering means arid altering tool cycling time. A further disadvantage resides with those tools utilizing oil, water or other liquicts as an expetldable fluid, as they are limited in the number of times they can be cycled Donnelly.
Finally, even thollgh some attempts have been made to combine multiple functions in a single tool, there has heretofore been no successful combination of more than Tao functions in a Sweeney tool.
I
SUMMARY OF THE INVENTION
In contrast to the prior art, the present invention comprises a Donnelly tool which is capable of performing in different modes of operation as a drill pipe tester valve, a circulation valve and a formation tester valve, as well as providing its operator with the ability to displace fluids in the pipe string above the tool with nitrogen or another gas prior to testing or retesting. This latter function is a valuable advantage in testing of gas formations or other wear or low pressure formations which may not flow when subjected to a large hydrostatic head or which may even be damaged by the weight of fluid in the string when the formation tester valve is opened.
The tool of the present invention is operated by a ball and slot type ratchet mechanism which provides -the desired opening and closing responsive to a series of annuls pressure increases and decreases of a drill pipe tester/
formation tester valve, a circulation valve and a nitrogen displacement valve, as well as changing between the modes of tool operation in which each of these valves function. More-over, the opening and closing as well as chanting between tool modes is effected without requiring the accurate monk-toning of pressure levels such as is necessary with tools that employ multiple pressure levels above a reference level or both pipe string and annuls pressures. The various tool modes are mutually exclusive that is to say, only one mode is operative at a time to ensure, for example, that the air-culation valve and tester valve cannot operate at the same time. In addition, the tool of the present invention is not limited to a given number of cycles in an of its modes, unlike prior art tools which employ shear pins or expendable fluids.
Further advantages over prior art tools include elimination of the need for a bypass below the tool since the design of the present invention precludes any operation of the circulating valve due to internal string pressure, including formation pressure from below the tool or acidizing or fracturing pressure from above applied to the formation.
Conversely, circulating fluid under pressure is positively isolated from the formation below, due to the aforesaid "lock-out" feature which precludes opening of the -tester valve in conjunction with the circulation valve. A further advantage of the circulation mode is the ability to circulate in either direction, so as to be able to spot chemicals or other fluids directly into the testing swing bore from the surface, and then open the tester valve to treat the for motion therewith. Also, pumping cold fluid through the tool will not prevent it from operating.
In addition to the advantages enumerated above, the present inventiorl includes a novel and unobvious operating mechanism for fluid dispkFtcement in the tool which avoids the use of the slow restructures and check valves of the prior art, such mechanism having utility in a wide variety OX
cleanly tools, which employ pressure changes us a power source, end therefore not being so limited to thy wool disk closed herein. Elimination ox a fluid metering system Erectly ~2;~3~
reduces tool cycling time and avoids the effects of viscosity changes in the metered fluid, as well as providing enhanced reliability. Another portion of -the operating mechanism of the present invention includes a non-rotating ratchet sleeve end a rotating ball follower which enhances the reciprocation of the operating mandrel of the tool as disclosed, but which is also not so limited to that particular tool, having utility in other Donnelly tools as well.
It should be noted that the tool as disclosed is lo not limited to the four-mode (drill pipe tester, formation tester, circulation valve, nitrogen displacement valve) operation format. It may be employed in conjunction with another, independently actuated formation tester valve there-below, and substitute an alternative ratchet slot program to operate in a three-mode (drill pipe tester, circulation valve, nitrogen displacement valve) format, or in a two-mode (circulation valve, nitrogen displacement valve) format.
BRIEF DESCRIPTION OF THE DRAWINGS
The present invention will be more fully understood by a review of the following detailed description of the preferred embodiment thereof, in conjunction with the accom-paying drawings, wherein:
FIG. l provides a schematic vertically sectioned view of a representative offshore platform from which testing may be conducted and illustrates a formation testing string or tool assembly in a submerged well bore at the lower end of a string of drill pipe which extends upward to the platform.
FIG. AYE comprise a vertical half section of the tool of the present invention in a formation testing mode.
So FITS. AYE comprise a vertical half-section of the -tool of the present invention in a drill pipe -testing mode.
FIGS. AYE comprise a vertical half-section of the tool of the present invention in a nitrogen displacement mode, ERGS AYE comprise a vertical half-section of the tool of the present invention in a circulating mode.
FIG. 6 comprises a development of the slot design employed in the preferred embodiment of the tool of the lo present invention.
FIGS. PA and 7B comprise an enlarged section of an alternative embodiment of the nitroc,7en displacement valve of the present invention.
FIGS, 8, 9 and lo comprise alternative slot designs which may be employed to alter the mode-changing sequence in the tool of the present invention, DETAILED DESCRIPTION OF THE PREFERRED
EMBODIMENT OF THE INVENTION
Referring to FIG, l, the present invention is shown schematically incorporated in a testing string deployed in an ocher oil or gas jell, Platform 2 is shown positioned over a submerged oil or gas well bore 4 located in the sea floor it Wylie bore penetrating potential producing formcttion 8.
Well bore 4 is shown to be fined with steel casing lo, which is cemented islet place. A subset conduit 12 extends from the deck lo of platform 2 into a subset Waldo 16, which includes blowout preventer 18 therein. Platfornt 2 carries a derrick 20 thereon, as well as a hoisting apparatus 22, net a pump I which communicates with the well bore 4 via collateral conduit 26, which extends below blackout preventer I
353~
A testing string 30 is shown disposed in well bore I, with blowout preventer 18 closed thereabout. Testing string 30 includes upper drill pipe string 32 which extends downward from platform 2 to Waldo 16, whereat is located hydraulically operated "test -tree" 34, below which extends intermediate pipe string 36. Slip join-t 38 may be included in stripy 36 to compensate for vertical motion imparted to platform 2 by wave action slip join-t 38 may be similar -to thaw disclosed in So Patent No. 3,354,950 to Hyde. Below slip joint 38, intermediate string 36 extends downwardly to multi-mode testing tool 50 of the present invention. Below combination tool 50 is lower pipe string 40, extending to tubing seal assembly 42, which stabs into packer I When set, packer 44 isolates upper well bore annuls 46 from lower well bore annuls 48. Packer 44 may be any suitable packer well known in the art, such as, for example, a waker Oil Tool Model D packer, an Otis Engineering Corporation Type W
packer, or Halliburton Services SHOP, RUTS or EN DRYWALL SO
packers Tubing seal assembly 42 permits testing string 30 to communicate with lower well bore 48 through perforated tail pipe 52. In this manner, formation luckless from potential producing formation 8 may enter lower well bore 48 through the perforations 54 in casing 10, and be routed into testing string 30.
After packer I is set in well bore 4, formation test controlling the flow of fluid from potential pro~EucincJ
eorrnation 8 through testing string 30 may be conducted using variations in pressure effected in upper annuls 46 by pump Al arid control conduit 26, with associated relies valves snot shown). Prior to thy actual test, Herr, the pressure :~2~3~
integrity of testing string 30 may be tested with the valve hall of the multi-mode tool closed in the tool's drill pipe tester mode. Tool 50 may be run into well bore 4 in its drill pipe tester mode, or it may be run in its circulation valve mode to automatically fill with fluid, and be cycled to its drill pipe mode thereafter. Formation pressure, temperature and recovery time may be measured during the flow test through the use of instruments incorporated in testing string 30 as known in the art as the ball valve in tool 50 of the I present invention is opened and closed in its formation -tester valve mode. Such instruments are well known in the art, and include both Bourbon -tube-type mechanical gauzes electronic memory gauges, and sensors run on wire line prom platform 2 inside testing string 30 prior to the test. If the formation to ye tested is suspected to ye weak and easily damageable by the hydrostatic head of fluid in testing string 30, tool 50 may be cycled to its displacement mode and nitrogen or other inert gas under pressure employed to disk place fluids from the string prior to testing or retesting.
It may also be desirable to treat the formation 8 in conjunction with the testing program while testincl string 30 is in place. Such a treating program is conducted by pUmpincJ various chemicals end other materials down the interior of testing string 30 at a pressure sufficient to force tune chemicals and other materials into the formation, and to possibly fracture the formation. Of course, the chemicals, materials and pressures employed will vary clependirlg on the formation characteristics and the desired changes thought to be elective in enhancing formation productivity. In this manner it is possible to conduct a 9 _ ~.ZZ~53;~
testing program, treat the formation and a second testing program to determine treatment effectiveness without removal of testing string 30. If desired, treating chemicals may be spotted in-to testing string 30 from the surface by placing tool 50 in its circulation valve mode, and displacing string fluids into the annuls prior to opening the valve ball in tool 50.
At -the end of the testing and treating programs, the circulation valve mode of tool 50 is employed, the circus lotion viva opened and formation fluids, chemicals and other injected materials in testing string 30 are circulated from the interior of testing string 30 into upper annuls 46 using a clean fluid, packer 44 is released (ox tubing seal 42 with-drawn if packer 44 is to remain in place) and testing string 30 withdrawn from well bore 4.
Referring to FIGS. AYE, tool 50 is shown in section, commencing at the top of the tool with upper adapter 100 having threads 102 therein at its upper end, whereby tool 50 is secured to drill pipe in the testing string. Upper acklpter 100 it secured to nitrogen valve housing 104 air:
threaded connection 106, housing 104 containing a valve assembly (not shown), such as is well known in the art, yin lateral bore 108 in the Lyle thereof, from which extends clownwarctly Longitudinal nitrogen charging channel lo.
Valve housirlg loll is secured by threaded connectiorl ll2 at its outer lower end to tubular pressure case 1l4, and ; by threaded collection 116 at its inner lower end to gay chamber mandrel lid, case 114 and mandrel 118 clcfi.iing pressurized gas chamber 120 end upper oil chamber l22, the two Boone separated by floatincJ annular piston 12~1.
- Lo -I I
The upper end of oil channel coupling 126 extends between case 114 and gas chamber mandrel 118, and is secured to the lower end of case 114 at threaded connection 128. A
plurality of longitudinal oil channels 130 (one shown) extend from the upper end of coupling 126 to the lower end thereof. Radially drilled oil fill ports 13~ extend from the exterior of tool 50, intersecting channels 130 and are closed with plugs 13~. Annular shoulder 136 extends radially inward from inner wall 138 of coupling 126. The lower end of coupling 126, including annular overshot 127, is secured at threaded connection 140 to the upper end of ratchet case 142, through which oil fill ports 1~4 extend at annular shoulder 146, being closed by plugs 148. At the lower end of ratchet case 142 are additional oil fill ports 150 closed by plugs 152 and open pressure ports 15~.
Ratchet slot mandrel 156 extends upward within the lower end of oil channel coupling 126. Annular ratchet chamber 158 is defined between mandrel 156 and case 142. The upper exterior 160 of mandrel 156 is of substantially uniform diameter, while the lower exterior 162 is of greater diameter so as to provide sufficient wall thickness for ratchet slots 16~. There are preferably two such ratchet slots 16~ of the configuration shown in FIG. 6 extending about the exterior of ratchet slot mandrel 156.
Ball sleeve assembly 166 surrounds ratchet slot mandrel 156, and comprises upper sleeve 168 including radially outwardly extending annular shoulder 170 having annular piston seat 17~ thereon. Below shoulder 170, ratchet piston support surface 173 extends to the lower end of upper sleeve 168, which is overshot by the upper end of lower ~.~2~353Z
sleeve 174 having annular piston seat 176 thereon, and to which is secured at threaded connection 178. Ball sleeve 180 is disposed at the bottom of lower sleeve 174, and is secured thereto at swivel bearing race 182 by a plurality of bearings lay. Two ratchet balls 186 each extend into a ball seat 188 on diametrically opposite sides of ball sleeve 180 and into a ratchet slot 164 of semicircular cross-section. Due to this structure when balls 186 follow the path of slots 164, ball sleeve 180 rotates with respect to lower sleeve 174, the remainder of ball sleeve assembly 166 does not rotate, and only longitudinal movement is transmitted to ratchet mandrel 156 by balls 186.
Upper annular ratchet piston 190 and lower annular ratchet piston 192 ride on piston support surface 173 on upper sleeve 168, coil spring 194 being disposed there-between. Upper ratchet piston 190 carries radial sealing surface 196 on its upper end, while lower ratchet piston 192 carries radial sealing surface 198 on its lower end.
The lower end 200 of ratchet slot mandrel 1~6 is secured at threaded connection 202 to extension mandrel 204 having relief ports 208 extending there through. Annular lower oil chamber 210 is defined by ratchet case 142 and extension mandrel 204. annular floating piston 212 slidingly seals the bottom of lower oil chamber 210 and divides it from well fluid chamber 21q into which pressure ports 154 opens. The lower end of ratchet case 142 is secured at threaded connect -lion 218, to extension case 216, which surrounds extension mandrel 204.
I
Circulation-displacement housing 220 is threaded at 222 to extension case 216, and possesses a plurality of circumferential spaced radially extending circulation ports 224 as well as a plurality of nitrogen displacement ports 226 extending through the wall -thereof.
Circulation valve sleeve 228 is threaded to extension mandrel 204 a-t 230. Valve apertures 232 extend through the wall of sleeve 228, and are isolated from circus lotion ports 224 by annular seal 234, which is disposed in seal recess 236 formed by the junction of circulation valve sleeve 228 with displacement valve sleeve 238, the two being threaded together at 240. The exterior of displacement valve sleeve 238 carries thereon downwardly facing radially extending annular shoulder 242 thereon, against whiz}- bears displacement spring 244. The lower exterior of displacement valve sleeve 238 is defined by displacement piston surface 246 upon which sliding annular displacement piston 248 rides.
Annular valve surface 250 of piston 248, and seats on elastomeric valve seat 254. Nitrogen displacement apertures 256 extend through the wall of displacement valve sleeve 238.
Valve seat 254 is pinched between sleeve 238 and shoulder 257 of sleeve 238 and flange 258 of operating mandrel 260, which is secured to sleeve 238 at threaded connection 262.
Seal carrier 264 surrounds mandrel 260 and the junction of mandrel 260 with sleeve 238 and is secured to mandrel 260 at threaded connection ~65. Square cross-section annular seal 266 is carried on the exterior of mandrel 260 adjacent flange 258, and is secured in place the upper end of seal carrier 26~.
-~2Z~353~
Below seal carrier 264, mandrel 260 extends down-warmly to exterior annular recess 267, which separates annular shoulder 268 from the main body of mandrel 260.
Collect sleeve 270,. having collect fingers 272 extending upward therefrom, engages operating mandrel 260 through the accommodation of radially inwardly extending protuberances 274 by annular recess 267. As is readily noted in FIG. 2G~ protuberances 274 and the upper portions of lingers 272 are confined between the exterior of mandrel 260 Rand the interior of circulation-displacement housing OWE
At the lower end of collect sleeve 270, coupling 276 comprising flanges 278 and 280, with exterior annular recess 282 there between, grips coupling 284, comprising inwardly extending flanges 286 and 288 with interior recess 2g0 there-between, on each of two ball operating arms 292. Couplings 276 and 284 are maintained in engagement by their location in annular recess 296 between ball case 294, which is threaded at 2g5 to circulation-displacement housing 220, and ball housing 298. Ball housing 298 is of substantially tubular configuration, having an upper smaller diameter portion 300 and a lower, larger diameter portion 302 which has two windows 304 cut through the wall thereof to accommodate the inward protrusion of lugs 306 from each of the two ball operating arms 292. Windows 304 extend from shoulder 311 downward to shoulder 314 adjacent threaded connection 316 with ball support 340. On the exterior of the ball housing 298, two longitudinal channels location shown by arrow 30~3) of arcuate cross-section and circumferential aligned with windows 30~, extend from shoulder 31Q downward to shoulder 311. Ball operating arms 292, which are of substantially the same arcuate cross-section as channels 308 and lower portion 302 of ball housing 298, lie in channels 308 and across windows 304, and are maintained in place by the interior wall 318 of ball case 294 and the exterior of ball support 340.
The interior of ball housing 293 possesses upper annular seat recess 320, within which annular ball seat 322 is disposed, being biased downwardly against ball 330 by ring spring 324. Surface 326 of upper seat 322 comprises a metal sealing surface, which provides a sliding seal with the exterior 332 of valve ball 330.
Valve ball 330 includes a diametrical bore 334 there through, of substantially the same diameter as bore 328 of ball housing 298. Two lug recesses 336 extend from the exterior 332 ox valve ball 330 to bore 33~.
The upper end 342 of ball support 340 extends into ball housing 298, and carries lower ball seat recess 344 in which annular lower ball seat 346 is disposed. Lower ball seat 346 possesses arcuate metal sealing surface 348 which slidingly seals against the exterior 332 of valve ball 330.
when ball housing 298 is made up with ball support 340, upper and lower ball seat 322 and 346 are biased into sealing engagement with valve ball 330 by spring 324.
Exterior annular shoulder 350 on ball support 340 is contacted by the upper ends 352 ox splints 354 on the exterior ox ball case 294, whereby the assembly of ball houslllcJ 294, ball operatinc3 arms 292, valve ball 330, ball seats 322 and 3~6 and sprincJ 324 are maintained in position inside of ball case 294. Splints 354 encage splints 356 on 353~
the exterior of ball support 340, and thus rotation of the ball support 340 and ball housing 298 within ball case 298 is prevented.
Lower adapter 360 protrudes at its upper end 362 between ball case 298 and ball support 340, sealing there between, when made up with ball support 340 at threaded connection 364. The lower end of lower adapter 360 carries on its exterior threads 366 for maying up with portions of a test string below tool 50.
When valve ball 330 is in its open position, as shown in FIG. 2G, a "full open" bore 370 extends throughout tool 50, providing an unimpeded path for formation fluids and/or for perforating guns, wire line instrumentation, etc.
OPERATION OF THE PREFERRED EMBODIMENT
OF THE PRESENT INVENTION
.
Referring to FIGS. 1 through 6, operation of the combination tool 50 of the present invention is described hereafter.
As tool 50 is run into the well in testing string 30, it is normally in its drill pipe tester mode shown in FIGS. AYE, with ball 330 in its closed position, with ball bore 334 perpendicular to tool bore 370. In this position, circulation ports 224 are misaligned with circulation aver-lures 232, seal 234 preventing communication there between. In a similar fashion, nitrogen misplacement ports 226 are offset from displacemerlt apertures 256 and isolated therefrom by seal 266. With respect to FIG 6, balls 136 will be in positions "a" in slots 164 as tool 50 is run into the well bore.
As tool 50 travels down to the level of the for-motion 8 -to be tested, at which position packer 44 is set, floating piston 212 moves upward under hydrostatic pressure, pushing ball sleeve assembly 166 upward, and causing balls 186 to move to positions "b", which dyes not change tool modes or open any valves. A pressure integrity check of the testing string 30 above tool 50 may then be conducted before flow testing the formation.
In order to open valve ball 330 to conduct a flow test of a formation, pressure is increased in annuls 46 by pump 24, via control conduit 26. This increase in pressure is transmitted through pressure ports 154 into well fluid chamber 214, where it acts upon floating piston 212. Piston 212 in turn acts upon a fluid, such as silicone oil, in lower oil chamber 210, which communicates with ratchet chamber 158.
In ratchet chamber 158, the pressurized oil pushes anisette upper ratchet piston 190, the oil being prevented from by-passing piston 190 by the metal to metal seal of sealing surface 196 on piston seat 172. Piston 190 therefore pushes against shoulder 170 on upper sleeve 168, which in turn pulls lower sleeve 17~, hall sleeve 180 and balls 186 Upward in slots 164. In this manner, balls 186 are moved to positions c, which has no effect on tool operation as balls 186 do not shoulder on the ends of slots 164 in this position. The aforesaid feature is advantageous in that it permits pressuring of -the well bore annuls 46 to test the seal of packer 44 across the well bore 4 without opening valve ball 330. By way of elaboration, when piston 190 reaches overshot 127, it is restrained from further upward movement, but fluid continues to act on shoulder 170 of upper sleeve 168, spreading piston seat 172 from seating surface 196, breaking the seal and dumping fluid past upper sleeve 168 into oil channels 130 and upper oil chamber 122, which equalizes -the pressures on both sides of piston 190 and stops the movement of ball sleeve assembly 166 and of balls 186 in slots 164. As the length of toe slot is greater than the travel of the ball sleeve assembly, balls 186 stop short of the slot end. As annuls pressure is bled off, the pressurized nitrogen in chamber 120 pushes against floating piston 124, which pressure is transmitted through upper oil chamber 122, channels 130 and ratchet chamber 158 against lower ratchet piston 176. As ratchet piston 176 is biased against piston seat 176, a metal to metal seal is effected between radial sealing surface 198 and seat 176. Ball sleeve assembly 166 is therefore biased downwardly, ratchet balls 186 follR~ing the paths of slots 164 to position do, where they shoulder on the ends of the slots. Tool 50 is now in its formation tester valve mode as shown in FIGS. AYE, but with valve ball 330 closed. When lower ratchet piston 192 reaches annular shoulder 146 in its downward travel, fluid continues to act on ball sleeve assembly 166, spreading sealing surface l98 from seat 176. Fluid is thus dumped below ball sleeve assembly 166 and is thereby equalized, stopping the travel of ball sleeve assembly 166, bells 185 and ratchet mandrel 156.
When the well bore annuls I 5 again pressured, ball sleeve assembly 166 moves upward and balls 1~6 shoulder in slots 16~ at position of roving ratchet mandrel 156 upward, which pulls extensioEl mandrel 204, circulation valve sleeve 228, displacement. valve sleeve 238 and operatirlg mandrel I
upward. Opportune mandrel 260 pulls collect sleeve on upward, 353~, which pulls arms 292 and rotates valve ball 330, aligning ball bore 334 with tool bore 370, permitting the formation to flow into the testing string 30 above tool 50. Tool 50 is now in the tester valve mode shown in FIGS. AYE with valve ball 330 open. When annuls pressure is released, balls 186 shoulder at position do, and close valve ball 330, but tool 50 is still in the tester mode of FIGS. AYE. The process of pressuring and releasing pressure may be continued to open and close ball 330 to flow test the formation until balls 186 reach positions do.
A subsequent increase in annuls pressure will shoulder balls 186 momentarily on inclined edges aye before moving further along slots 164 past positions f but valve ball 330 will not open. When pressure is released again, balls 186 move downward and shoulder in positions f, moving ratchet mandrel 156 downward and tool 50 out of its formation tester mode and back into the nitrogen displacement mode of FIGS. AYE. As can readily be seen in Fig. OH, protuberances 274 on collect sleeve fingers 272 are disengaged from open-cling mandrel 260 in this mode, preventing rotation and no-opening of ball 330.
A subsequent increase and decrease of annuls pressure causes balls 186 to climb further in slots 164 past positions g, and then to push ratchet mandrel 156 downward, moving tool 50 to its circulation valve mode shown in ITS
AYE. fluid may be circulated into the testing string 30 from annuls 46 through circulation ports 224, which are aligned with circulation apertures 232, ball valve 330 in its closed position end nitrogen displacement ports 22~ offset prom apertures 256~ Fluid ma also ye circulated into annuls 46 3.2~3S32 from the testing string 30, as when it is desired to spot formation treatment chemicals into the string prior to an acidizing or fracturing operation. As may be easily observed in FIG. 5G, operating mandrel 156 has continued to travel downward within collect sleeve 270 but out of engagement with protuberances 274.
Subsequent pressure increases and decreases in the annuls will move balls 186 sequentially to positions hi, if, ho, it, and ho without changing -tool 50 prom its circulation mode, as balls 186 do not shoulder in slots 164. This provides a margin of safety against changing of tool modes due to inadvertent pressure cycling in -the annuls during circulation.
As annuls pressure is decreased after balls 186 reach positions ho, they will move downward past positions j, whereupon a subsequent annuls pressure increase will shoulder balls 186 in positions j, moving ratchet mandrel 156 upward and tool 50 back into its nitrogen displacement mode of FIGS. AYE. It treatment chemicals have no-t been spotted in the string, and if it is desired to displace fluid out of the testing string 30 prior to a further test, as where the formation has not flowed initially due to hydrostatic head ox fluid in the string, nitrogen may be introduced into the testing string 30 under pressure. In this mode, valve ball 330 is closed and circulation ports 22~ offset from apertures 232, but nitrogen displacement ports 226 are aligned with apertures 2~6. The pressurized nitrogen isle act upon disk placement piston 248, moving it away from seat 254, and permit fluid in the siring. to exit into the well bore annuls. When pressure it reduced in the string, annuls ~.'2~Z~3S3;~
pressure outside tool 50 will act upon the upper end of disk placement piston 248 through circulation ports 22~, and firmly press valve surface 250 against seat 254, preventing reentry of fluid into the string.
As in the circulation mode, several subsequent increases and decreases in annuls pressure will move balls 186 in slots 164, but will not change the mode of tool 50. As pressure is decreased and increased sequentially when balls are in positions j, they move to positions Al, 11, k2 and 12.
When pressure is again decreased with balls 1~6 in position 12, they will move downward in slots 16~ past position m, where a subsequent increase will shoulder balls 186 out on slots 164 in positions m, changing tool mode to the drill pipe tester modify FIGS. AYE, offsetting nitrogen disk placement pouts and apertures, leaving circulation ports and apertures offset, and leaving valve ball 330 closed.
further decrease in pressure will return balls 186 to post-lions a, and the operator may begin another cycle of tool 50, such as to treat the formation and retest it after the treat-mint, or test it with the string unloaded of fluid.
By way of further explanation of the mode changing and operating sequence of tool 50, the reader should note that the tool only changes mode when balls 1~6 shoulder at specific foreshortened positions on slot 164 during cycling of the tool. For example, tool 50 changes mode a positions do, do, f, g, j end m. Four mode changes are effected by annuls pressure decrease, and two by an increase. The pressure increases which shoulder balls 1~6 in positions I
through en do not produce a mode change because balls 1~6 travel within a restricted longitudinal range limited ho the I
dumping of the operating fluid in the tool by pistons 190 and 192, and the configuration of the slots 164 from positions of through en does not permit balls 186 to climb in slots 16~ to change tool modes.
OPERATION OF A SECOND PREFERRED EMBODIMENT OF
THE PRESENT INVENTION
As has previously been noted, tool 50 of the present invention may be changed to operate in a three-mode sequence as a drill pipe testes, circulation valve and nitrogen displacement valve in conjunction with a separate tester valve there below in the string by merely removing ratchet mandrel 156 and inserting another mandrel 1~6' having a different slot program 164' therein. Such a mandrel slot program 16~' is shown in FIG. 8. In all respects other than substitution of mandrel 156' for mandrel 156, tool 50 remains structurally the same even though its modes of operation have been altered.
With slot 164', tool So is run into the well bore in its drill pipe tester mode with balls 186 in positions a as shown in ERG. 8 and tool 50 in the mode shown in FIGS.
AYE. As tool 50 travels down the well bore, hydrostatic nulls pressure will move balls 186 to position b. As village ball 330 remains closed, an integrity test of the drill pipe may be conducted. The first increase in annuls pressure subsequent to the drill pipe test will move balls 186 to positions c, which will not change tool mode, And a subsequent decrease and increase will shoulder balls on slot 16~' at position d, which will rotate alluvia ball 330 to an open position, aligning bore 334 with tool bore 370 as shown in FIGS. AYE. This same pressure increase will haze opened ~Z~2~353~
the ball of the tester valve there below, which may be a valve such as are disclosed in US. Patent No 3,964,544, 3,976,136, 4,422,506, 4,429,748, as well as others known in the art. The formation then flows through the tester valve and tool 50 during the test. When annuls pressure is de-creased to close the tester valve, the decrease will move balls 186 to positions of,. which will not close valve ball 330 because balls 186 do not shoulder on slots 164'.
Subsequent pressure increases and decreases to flow test the well via the tester valve will move balls 186 sequentially to P I en' f2~ eye f3 and en, during which valve ball 330 of tool 50 will remain open. During the next subsequent annuls pressure increase when in position en, balls 186 will climb in slot 164' past positions g, valve ball remanning open. When annuls pressure is relieved, however, balls 186 will shoulder in positions g and move ratchet mandrel 1S6' downward, closing valve ball 330 and returning tool 50 to its drill pipe tester mode shown in FIGS. AYE.
Another increase and decrease in annuls pressure will move balls 186 to shoulder in positions h, changing tool to the nitrogen displacement mode of FIGS. AYE. A second increase/decrease pressure cycle will move balls 186 to positions i and tool 50 to the circulation mode of FIGS.
ASSAY.
Subsequent increases and decreases in annuls pressure will ratchet balls 186 through positions Jo it it it, Jo, and down past I without changing tool mod, after which an increase will shoulder balls 1~36 in positions Al, changing tool I to the neutron displacement mode ox FOGS.
AYE.
I Z
Further annuls pressure cycling in decrease/
increase sequence will move balls 186 to positions 11, k2, 12, k3 and down past positions m without changing tool mode.
A subsequent pressure increase will shoulder balls 186 in positions m and change tool 50 to its drill pipe tester mode of FIGS. AYE. Further pressure cycling of the annuls will begin another tool cycle.
As noted with respect to slot 164, tool 50 only changes mode when balls 186 shoulder in foreshortened paths in the slot. In slot 164' for example, tool mode changes only in ball positions d, g, h, if, Al, and m. In all other instances, balls 186 merely travel slots 164' with no effect on tool operation.
ALTERNATIVE EMBODIMENTS OF THE
PRESENT INVENTION
A
it is also possible to reprogram tool So of the present invention to effect modes of operation other than those disclosed with respect to the first and second preferred embodiments.
For example, referring to FIG. 9, the program of slot 164" is shown. Using mandrel 156'l with slot 164", tool 50 is run into the well bore in its drill pipe tester mode of FIGS. AYE, with balls 186 in positions a in slots 164.
Going Donnelly, balms 186 will be forced upward to positions b by hydrostatic pressure in the annuls. A drill pipe integrity test may be conducted when tool I reaches the jest level in the well bore.
After the packer is set, the formation may be flow tested by raising annuls pressure, lowering it and raising I it again, which moves balls up through portions c, down past - Al -~2~53~2 portions do, and up to do whereat balls 186 shoulder and open valve ball 330, tool 50 being in the tester valve mode of FIGS. AYE. A subsequent decrease in annuls pressure will move balls 186 to position of, which will retain valve ball 330 in an open position. Another increase/decrease cycle will close valve ball 330 due to shouldering of balls 186 in positions if and downward movement of ratchet mandrel 156.
Another increase/decrease cycle will result in ball movement to positions go, and down past do, with valve ball 330 remaining closed. The next increase/decrease opens valve ball 330 when balls 186 shoulder in positions do, and leave valve ball 330 open when balls 186 travel to positions en. The following increase/decrease shoulders balls 186 in positions f2 as annuls pressure is relieved, closing valve ball 330. A
further increase/decrease moves balls 186 to position go an back down below do, after which the next subsequent increase/decrease shoulders balls 186 in positions do, opening valve ball 330 and leaving it open as balls 186 land at position en.
To continue the tool cycle, an annuls pressure increase/decrease moves balls 186 to f3, closing valve ball 330. Balls 186 climb slots 164"' with the next lncrease/decrease to position h, whereat tool 50 is shifted to its nitrogen displacement mode of FOGS. AYE, and then to its circulation mode of FIGS. AYE when annuls pressure is again cycled and balls 186 shoulder in positions it.
The next three increase/decrease cycles in annuls pressure will move balls 186 through positions if, it, Jo, it, Jo and back down past position Al. During this travel, balls 186 do not shoulder, and the tool 50 does not change mode. However, the next subsequent increase in pressure will shoulder balls 186 in position Al, change tool mode to the nitrogen displacement mode of FIGS. AYE.
The next two decrease/increase pressure cycles move balls 186 through positions 11, k2, 12 and k3 without change in tool mode. During the following decrease/increase cycle, however the tool is moved back to its drill pipe test mode of FIGS. AYE when balls 181 move downward below positions on the decrease and then shoulder as pressure is increased. When annuls pressure is next decreased, balls 186 move back to positions a for commencement of a new tool cycle.
As was noted with respect to the previous operating mandrels 156 and 1S6' mandrel 156`' does not move longitu-finally to operate valve hall 330 and to change tool modes unless balls 186 shoulder in foreshortened legs of slots 164". In slots 164", only positions do, f3, h, if, Al, end To produce a change of mode. Positions do, if, do, En, do and f3, however, all serve to open and close, respectively valve ball 330.
With the slot program employed in slot 16~1", the test operator must positively pressure the annuls and then relieve pressure for valve ball 330 to move from a closed to an open position and vice-versa, which feature prevents a shutoff in the middle of a flow test if annuls pressure is reduced inadvertently. Furthermore, valve ball 330 may he left open after the formation test and circulatioTI, to let ~estincJ string 30 drain of fluid as it is removed from well bore 9.
I
Another embodiment of the present invention may be effected utilizing yet another slot program, illustrated in FIG. 10 as slot 164"' on mandrel 156"'. With slots 164"', tool 50 is restricted to a two-mode operation, circulation valve, which would be preferred in some areas ox the world which do not conduct drill pipe tests prior to flow testing the well, and which use a separate tester valve below tool 50.
With slots 164"', ratchet balls 186 commence in possessions a, and move to be as tool 50 travels down the well bore. Valve ball 330 is open. A first annuls pressure increase after packer 44 is set will result in ball movement to positions at, and subsequent decrease/increase cycling will move balls 186 through positions do, c2, do and C3 to do. The next three increase/decrease pressure cycles will result in balls 186 climbing slots 164"' to positions e, which closes valve ball 330; positions f, which places tool 50 in its displacement valve made; and position go, which places tool 50 in its circulation valve mode The next three 20increase/decrease pressure cycles will result in free ball movement through positions hi, go, ho, go and ho past if, without moving tool 50 from its circulation valve mode.
However, a subsequent increase will change tool mode to disk placement valve, as balls 186 shoulder in positions il. This mode is maintained through the next two decrease increase cycles with tree ball travel. The Nat decrease increase cycle then moves balls 186 to shoulder in positions k, which offsets both displacement ports 226 from displacemerlt aver-lures 256 and circulation ports 224 from circulation aver-Tories 232 while leaving valve ball 330 closed. The Nikko - I -3S3~
subsequent decrease/increase cycle will again open valve ball 330 with balls 186 in positions 1, and an annuls pressure decrease will place balls back in positions a for another tool cycle. In slots 164"', balls 186 shoulder in positions en I go k and 1-ALTERNATIVE EMBODIMENT OF TOE DISPLACEMENT VALVE
OF THE PRESENT INVENTION
FIGS. PA and 7B illustrate an alternative construe-lion for a nitrogen displacement valve assembly which may be employed in tool 50. Valve assembly 400 includes an outer circulation-displacement housing 220' with slightly longer spacing between circulation ports 224 and displacement aver-lures 234 than in standard housing 220. At its upper end, housing 220' is secured at threaded connection 222 to extension case 216, while at its lower end (not shown) it is secured to ball case 294. Within tool 50, extension mandrel 204 is secured at threaded connection 230 to circulation valve sleeve 228, through which circulation apertures 23Z
extend. Sleeve 228 is threaded to displacement valve sleeve 238', seal 234 being maintained in an annular recess 236 there between to isolate circulation apertures 232 from circus lotion ports 224.
On the exterior of displacement valve sleeve 238' lie annular marker grooves 420 three grooves), 422 (two grooves) and 424 ( one groove), the purpose of which will be explained hereafter. Below the marker grooves displacement apertures 256 e~tencl through the wall of sleeve 238' adjacent obliquely inclined annular wall 416, which it a part of dip-placement assembly 400.
- I -lo it Flapper mandrel 406 slides on the exterior of sleeve 238' below wall 416, and is restricted in its longitu-dial travel by the abutment of elastomeric seal 414 against wall 416 at its upper extent, and by the abutment of shoulder 408 against stop 404 extending upward from shoulder 402 on operating mandrel 260'. Stops 404 prevent pressure locking of shoulder 408 to shoulder 402. Seal 266 is maintained in a recess between annular shoulder 258' on mandrel 260' and seal carrier 264, which surrounds threaded connection 262 between sleeve 238' and operating mandrel 260', and is itself secured to operating mandrel 260' at threaded connection 265.
Flapper mandrel 406 carries thereon a plurality of frustoconical valve flappers 412 thereon, which are bonded to mandrel 406 adjacent annular shoulders 410.
Displacement assembly 400 is placed in its opera-live mode in the same fashion as the displacement mode of tool 50 in FIGS. 2-5, that is by longitudinally moving the internal assembly connected to ratchet mandrel 156 through the interaction of balls 186 in slots 164. However, unlike displacement piston 248 which is spring-biased toward a closed position against seat 25~ (FIGS. 2E-F, 3E-F) and is moved therefrom by nitrogen slowing under pressure throllgh apertures 256 (FIGS. 4E-F), mandrel 406 operates when placed adjacent displacement ports 226 FIGS. AHAB) throuc3h downward movement against stops 404 followed by collapse of flappers 412 against mandrel 406 to permit exit through ports 226 of -the fluid in the string and the pressurized nitrogen impelling it into the well bore annuls.
~1~2;~ 32 If pressure is removed from the bore 370 of tool 50, the hydrostatic head (and pressure) in the annuls will expand flappers 412 against circulation-displacement housing 220' and move mandrel 406 upward against wall 416, whereon elastomeric seal 414 will seat, preventing reentry of annuls fluids into bore 370.
An added feature-of assembly 400 is the ease of identification of tool mode through the use of marker grooves 420, 422 and 424. For example, when tool 50 is in its circus lotion mode, circulation ports 224 will be aligned with air-culation apertures 232 and no grooves will be visible. When tool 50 is in its displacement mode (FIGS. AHAB, grooves 420 will be visible. When valve ball 330 is closed, grooves 422 will be visible, and when valve ball 330 is open, groove 420 will be visible. With knowledge of which ratchet mandrel is employed in tool 50 and the initial portion desired, the tool will then be easily able to ensure placement of tool 50 in its proper mode for running into the well bore.
It is thus apparent that a novel and unobvious multi-mode testing tool has been developed, which further includes a novel and unobvious operating mechanism and valves therein. It will be readily apparent to one of ordinary skill in the art that numerous additions, deletions and modify-cations may be made to the invention as disclosed in its preferred and alternative embodiments as disclosed herein.
For example, tool 50 might employ an all-oil operating biasing mechanism such as is disclosed in US. Patent Nos.
4,109,724, 9,109,7~5, 4,444,268 and 4,4~l8,254; the nitrogen displacement valve might be placed above the circulation 3Q valve in the tool; alternative pressure-responsive check -ISLE
valve designs might be employed as displacement valves;
Belleville or other springs might be substituted for the coil springs shown in tool 50; the operating mechanism of the tool, including nitrogen and/or oil chambers, the ratchet mandrel and the ball sleeve assembly could be placed at the bottom of the tool or between the ends thereof; the ratchet balls could be seated in recesses on a mandrel and a rotating ratchet sleeve with slots cut on the interior thereon might be employed there around and joined by swivel means to a sleeve assembly carrying annular pistons 190 and 192 thereon;
a ratchet sleeve might be rotatable mounted about a separate mandrel and ratchet balls mounted in a non-rotating sleeve assembly thereabout; a sleeve-t~pe valve such as is disclosed in I Patent RYE 29,562 might be utilized to close bore 370 through tool 50 in lieu of a ball velvet an annular sample chamber might be added to tool 50 such as is also disclosed in the aforesaid US. Patent I 29,5~2; a second valve ball might be included longitudinally spaced from valve ball 330 and secured to operating mandrel 260 to form a ball-type sampler having a mechanism Seymour to those disclosed in US.
Patent Nos. 4,06~,937, ~,270,610 and ~,311,197; the valve ball 330 could be placed at the top of the tool and employed for drill pipe test purposes only with another tester valve run below the tool, as has been heretofore suggested; an annular piston having a longitudinal channel therein with a resiliently biased check valve closure member and valve seats at each end thereof may be substituted for the piston sleeve and pistons of the preferred embodiment, using for stop meal-s a pin or rod adapted to push the check valve closure member back from its seat aye each limit ox piston travel to dump ~.~22~53~2 fluid therapist. These and other changes may be effected without departing from the spirit and scope of the claimed nvent1on.
This application is a divisional of Canadian Patent Application No. 479,772, filed February 20, 1935.
Claims (3)
1. A method of operating a multi-mode downhole tool including a drill pipe tester mode and a circulation mode and having longitudinal bore extending therethrough, comprising:
running said tool into a well bore on a pipe string;
setting said packer in said well bore below said tool to isolate the well bore above the packer from that therebelow;
pressure-testing the integrity of said pipe string against a closed bore closure valve disposed in the bore of said tool while said tool is in said drill pipe tester mode; and pressure-testing the seal between said set packer and the wall of said well bore while said tool is in said drill pipe tester mode by increasing well bore pressure above said set packer without opening said bore closure valve or changing said tool to a different operating mode.
running said tool into a well bore on a pipe string;
setting said packer in said well bore below said tool to isolate the well bore above the packer from that therebelow;
pressure-testing the integrity of said pipe string against a closed bore closure valve disposed in the bore of said tool while said tool is in said drill pipe tester mode; and pressure-testing the seal between said set packer and the wall of said well bore while said tool is in said drill pipe tester mode by increasing well bore pressure above said set packer without opening said bore closure valve or changing said tool to a different operating mode.
2. The method of claim 1, further comprising changing said tool to a displacement mode through said sequential changes of well bore pressure, and displacing fluid out of said pipe string and into said well bore by introducing gas under pressure into said pipe string from the surface while said tool is in said displacement mode.
3. The method of claim 1 or 2, further including circulating fluid between said pipe string and said well bore while said tool is in said circulation mode.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA000528674A CA1228532A (en) | 1984-04-03 | 1987-01-30 | Method of operating a multi-mode downhole tool |
Applications Claiming Priority (4)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US596,321 | 1984-04-03 | ||
| US06/596,321 US4633952A (en) | 1984-04-03 | 1984-04-03 | Multi-mode testing tool and method of use |
| CA000474772A CA1228800A (en) | 1984-04-03 | 1985-02-20 | Tool for use in a testing string disposed in a well bore |
| CA000528674A CA1228532A (en) | 1984-04-03 | 1987-01-30 | Method of operating a multi-mode downhole tool |
Related Parent Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000474772A Division CA1228800A (en) | 1984-04-03 | 1985-02-20 | Tool for use in a testing string disposed in a well bore |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1228532A true CA1228532A (en) | 1987-10-27 |
Family
ID=25670594
Family Applications (9)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000528672A Expired CA1228801A (en) | 1984-04-03 | 1987-01-30 | Method of operating a multi-mode downhole tool |
| CA000528669A Expired CA1229038A (en) | 1984-04-03 | 1987-01-30 | Operating assembly for a downhole tool |
| CA000528671A Expired CA1229040A (en) | 1984-04-03 | 1987-01-30 | Displacement valve for use in displacing fluid in a downhole tool |
| CA000528673A Expired CA1228802A (en) | 1984-04-03 | 1987-01-30 | Operating assembly for a downhole tool |
| CA000528668A Expired CA1229037A (en) | 1984-04-03 | 1987-01-30 | Ratchet assembly for transmitting movement in a downhole tool |
| CA000528674A Expired CA1228532A (en) | 1984-04-03 | 1987-01-30 | Method of operating a multi-mode downhole tool |
| CA000528667A Expired CA1229041A (en) | 1984-04-03 | 1987-01-30 | Multi-mode testing tool for use in a well bore |
| CA000528670A Expired CA1229039A (en) | 1984-04-03 | 1987-01-30 | Indexing assembly for a downhole tool |
| CA000547555A Expired CA1246987A (en) | 1984-04-03 | 1987-09-22 | Multi-mode testing tool and method of testing |
Family Applications Before (5)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000528672A Expired CA1228801A (en) | 1984-04-03 | 1987-01-30 | Method of operating a multi-mode downhole tool |
| CA000528669A Expired CA1229038A (en) | 1984-04-03 | 1987-01-30 | Operating assembly for a downhole tool |
| CA000528671A Expired CA1229040A (en) | 1984-04-03 | 1987-01-30 | Displacement valve for use in displacing fluid in a downhole tool |
| CA000528673A Expired CA1228802A (en) | 1984-04-03 | 1987-01-30 | Operating assembly for a downhole tool |
| CA000528668A Expired CA1229037A (en) | 1984-04-03 | 1987-01-30 | Ratchet assembly for transmitting movement in a downhole tool |
Family Applications After (3)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000528667A Expired CA1229041A (en) | 1984-04-03 | 1987-01-30 | Multi-mode testing tool for use in a well bore |
| CA000528670A Expired CA1229039A (en) | 1984-04-03 | 1987-01-30 | Indexing assembly for a downhole tool |
| CA000547555A Expired CA1246987A (en) | 1984-04-03 | 1987-09-22 | Multi-mode testing tool and method of testing |
Country Status (1)
| Country | Link |
|---|---|
| CA (9) | CA1228801A (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2555637B (en) | 2016-11-07 | 2019-11-06 | Equinor Energy As | Method of plugging and pressure testing a well |
-
1987
- 1987-01-30 CA CA000528672A patent/CA1228801A/en not_active Expired
- 1987-01-30 CA CA000528669A patent/CA1229038A/en not_active Expired
- 1987-01-30 CA CA000528671A patent/CA1229040A/en not_active Expired
- 1987-01-30 CA CA000528673A patent/CA1228802A/en not_active Expired
- 1987-01-30 CA CA000528668A patent/CA1229037A/en not_active Expired
- 1987-01-30 CA CA000528674A patent/CA1228532A/en not_active Expired
- 1987-01-30 CA CA000528667A patent/CA1229041A/en not_active Expired
- 1987-01-30 CA CA000528670A patent/CA1229039A/en not_active Expired
- 1987-09-22 CA CA000547555A patent/CA1246987A/en not_active Expired
Also Published As
| Publication number | Publication date |
|---|---|
| CA1228801A (en) | 1987-11-03 |
| CA1229039A (en) | 1987-11-10 |
| CA1229041A (en) | 1987-11-10 |
| CA1246987A (en) | 1988-12-20 |
| CA1229037A (en) | 1987-11-10 |
| CA1228802A (en) | 1987-11-03 |
| CA1229040A (en) | 1987-11-10 |
| CA1229038A (en) | 1987-11-10 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| MKEX | Expiry |